Method and apparatus for transporting compressed natural gas in a marine environment

ABSTRACT

A method and apparatus for transporting or storing compressed natural gas in a marine environment includes the providing of a heavy lift vessel that has a weather deck area that is bounded by forward and aft, port and starboard sides or walls that extend above the weather deck. A buoyant module is provided that contains a pipeline, the pipeline including multiple alternating straight sections and bend sections and multiple layers. The pipeline is supported at differing elevations within the module interior so that the various sections of the pipeline are preferably spaced apart to enable visual and/or remote exterior inspection (e.g. video, radar, x-ray, acoustic, or other exterior, non-destructive test) of the outer surface of the pipeline. The pipeline has a continuous bore that is piggable for internal inspections. The module can be transferred to a heavy lift vessel or can be used as flotation. The combination of heavy lift vessel and module can travel to a selected location for loading and unloading compressed natural gas. The module can be placed in a marine environment to serve as a storage facility for compressed natural gas.

CROSS-REFERENCE TO RELATED APPLICATIONS

[0001] Priority of U.S. Provisional Patent Application Serial No.60/391,276, filed Jun. 25, 2002, incorporated herein by reference, ishereby claimed.

STATEMENT REGARDING FEDERALLY SPONSORED RESEARCH OR DEVELOPMENT

[0002] Not applicable

REFERENCE TO A “MICROFICHE APPENDIX”

[0003] Not applicable

BACKGROUND OF THE INVENTION

[0004] 1. Field of the Invention

[0005] The present invention relates to storage and transportation ofcompressed natural gas under pressure in a self-sustaining modulehousing a continuous pipeline. The modular system can be used for thestorage of compressed natural gas in a marine environment or in aterrestrial environment. Moreover, through the use of a speciallyconfigured new, purpose built, or existing, semi-submersible heavy liftvessel, heavy lift vessel or other special built transport vessel(collectively herein also referred to as “transport vessel”), themodular system can also be used for transportation of compressed naturalgas in a marine environment. A heavy lift vessel is designed to carryvery large, bulky cargoes on an open deck and a semi-submersible vesselis designed with a ballast system to enable the cargo deck or weatherdeck to submerge below the water, allowing the floating cargo to bepositioned over the weather deck area and secured on the deck when thevessel is de-ballasted and the deck rises above the water.

[0006] More particularly, the present invention relates to an improvedmethod and apparatus for 1) storage of compressed natural gas in amodule housing a pipeline at the source of natural gas, 2)transportation of compressed natural gas using a specially configurednew, purpose built, or existing, semi-submersible heavy lift vessel,heavy lift vessel or other special built transport vessel that carriessuch module housing a pipeline and 3) offloading and storage ofcompressed natural gas in a module housing a pipeline at the terminallocation or destination, while the module is 1) in a floating mode onthe surface of the water, or 2) suspended beneath the surface of thewater, or 3) supported with a specially configured new, purpose built,or existing vessel. The module can be transferred to or from the marinetransport or storage vessel from a dock or from an adjacent waterwayhaving sufficient draft to float the module and to float the speciallyconfigured new, purpose built, or existing, semi-submersible heavy liftvessel or other special built transport vessel (herein also referred toas “transport vessel”). The module may also be removed from the marinetransport vessel and utilized for free standing storage of compressednatural gas on land or in a marine environment either on the surface orsubmerged below the water surface. The module has an interior with acontinuous pipeline comprised of metal and/or light weight compositematerial that includes multiple layers, each layer having generallystraight sections and curved sections that are preferably formed byinduction bending of the metal pipe, with or without compositereinforcing, or custom built using only light weight composite material,or a combination of metal and light weight composite material. Thecontained pipeline is continuous and is supported, in layers, by a pipesupport system that is also the subject of this invention.

[0007] 2. General Background of the Invention

[0008] Marine vessels have been used to transport compressed gas in themedium known as liquid petroleum gas (LPG) typically in a mixture of c2,c3, and c4 linear saturated hydrocarbons at a relatively low pressureand at ambient temperature. In such a situation, the marine vesseltypically has a plurality of containers that carry the compressed gas.

[0009] In the prior art, ship based systems have been proposed fortransporting compressed natural gas (comprising chiefly methane (c1)with small quantities of c2 through c4 saturated hydrocarbons). Suchsystems have typically proposed a plurality of containers that are influid communication using a manifold system. One system employs a spoolwith pipe wrapped upon the spool, each layer contacting the previouslayer.

[0010] An example of a ship based system for a compressed natural gastransport is U.S. Pat. No. 5,803,005 issued to Stenning et al. TheStenning '005 patent discloses a ship based system for compressednatural gas transport that utilizes a ship having a plurality of gascylinders. The plurality of gas cylinders are configured into aplurality of compressed gas storage cells. Each compressed gas storagecell consists of between 3 and 30 gas cylinders connected by a cellmanifold to a single control valve. A high pressure manifold is providedincluding means for connection to(shore terminals. A low pressuremanifold is provided including means for connection to shore terminals.A sub manifold extends between each control valve to connect eachstorage cell to both the high pressure manifold and the low pressuremanifold. Valves are provided for controlling the flow of gas throughthe high pressure manifold and the low pressure manifold.

[0011] Two additional Stenning et al. patents have issued that aredirected to a ship based gas transport system. These include U.S. Pat.Nos. 5,839,383 and 6,003,460. In the Stenning '383 and '460 patents, agas storage system formed of continuous pipe is wound in plural layers,each layer having plural loops. The pipe is said to be distributedwithin a container, which may serve as a carousel for winding the pipeand as a gas containment device. When containers, each containing acontinuous pipe are stacked upon each other, the weight of uppercontainers is said to be born by the walls of lower containers, thuspreventing lower layers of pipe from suffering stresses due to crushingby upper layers. The Stenning '383 and '460 patents disclose a method oftransporting gas to a gas distribution facility including obtaining asupply of gas at a gas supply point remote from the gas distributionfacility, injecting the gas into a continuous pipe bent to form plurallayers, each layer including plural loops of pipe, transporting thecontinuous pipe along with the gas to the gas distribution facilitypreferably in a ship and discharging the gas at the gas distributionfacility. It is preferred that cooling of the pipe during discharging ofthe gas be conserved so that during subsequent filling the pipe isinitially cool. During filling, the gas pressure is said to bemaintained as constant as possible for example by controlled release ofan incompressible liquid from the pipe as the pipe is filled with gas.Energy from the incompressible liquid may then be recovered ordissipated outside of the pipes.

[0012] A report entitled “Clarification of Certain Issues Pertaining tothe Marine Transportation of C.N.G.” was prepared for Entergy PowerGroup by Bill Bishop, then of PB-KBB, an engineering firm with officesin Houston, Texas, in August of 1995. The Bishop report provides adesign of a pipe storage transportation system for gas. The report alsoconsiders the option of using a ship or a barge for this purpose.

[0013] Patent application No. 2002/0046457A1 was published Apr. 25,2002, naming inventors as William Bishop, Charles White and DavidPemberton. The published Bishop et al. patent application discussesmethods and apparatus for transporting compressed gas. The methods andapparatus for transporting compressed gas include a gas storage systemhaving a plurality of pipes connected by a manifold whereby the gasstorage system is designed to operate in the range of the optimumcompressibility factor for a given composition of gas. The pipe for thegas storage system is said to be preferably large diameter pipe made ofa high strength material whereby a low temperature is selected which canbe withstood by the material of the pipe. This publication states thatby knowing the compressibility factor of the gas, the temperature, andthe diameter of the pipe, the wall thickness of the pipe may becalculated for the pressure range of the gas at the selectedtemperature. The publication states that the gas storage system mayeither be modular or be part of the structure of a vessel fortransporting the gas to the storage system. Since the pipe provides abulkhead around the gas, the gas storage system may be used in a singlehull vessel. The gas storage system further includes enclosing the pipesin a chilled nitrogen atmosphere. A displacement fluid may be used tooffload the gas from the gas storage system. A vessel with the gasstorage system designed for a particular composition gas produced at agiven location is used to transport gas from that producing location tooffloading ports hundreds, or thousands, of miles from the producinglocation.

BRIEF SUMMARY OF THE INVENTION

[0014] The present invention provides an improved method and apparatusfor transporting compressed natural gas in a marine environment andstoring compressed natural gas in a marine environment or terrestrialenvironment. The method of the present invention includes the step ofproviding a heavy lift vessel that has a weather deck or lower deckarea. This weather deck or lower deck is bounded by port and starboardsides that extend above the weather or lower deck.

[0015] A hollow buoyant module is provided that contains a pipeline, thepipeline including multiple layers, each layer having alternatingstraight pipe sections and bend sections. The pipeline can be continuouspipeline or comprised of various joints of pipe. Preferably the pipelinewill have a bore of a substantially constant diameter. The pipeline caninclude multiple substantially straight metal pipe sections having bendsat either end portion that are formed using induction bending. Thepipeline can include straight or bend sections manufactured usingmetallic pipe wrapped with light-weight, high strength compositematerials composed of carbon fiber, fiberglass, aramid or other hightensile strength filaments bound by polymeric resin.

[0016] The pipeline can include straight or bend sections manufacturedusing light-weight, high strength composite materials composed of carbonfiber, fiberglass, aramid or other high tensile strength filaments boundby polymeric resin.

[0017] The multiple pipeline layers are supported at differingelevations within the module. The module can then be transferred to thetransport vessel. The transport vessel, equipped with module andpipeline, can then travel to a natural gas source and be loaded withcompressed natural gas.

[0018] In the preferred embodiment, the transfer of the module to thesemi-submersible heavy lift vessel includes the step of ballasting thesemi-submersible heavy lift vessel and module relative to one another.

[0019] In the method of the present invention, the buoyant modulepreferably provides a top, bottom and a plurality of side walls.

[0020] In the preferred method, the transport vessel is asemi-submersible heavy lift vessel and the method includes ballastingthe semi-submersible heavy lift vessel relative to the module when themodule is to be loaded on the transport vessel or unloaded from thetransport vessel.

[0021] Ballasting of the semi-submersible heavy lift vessel ispreferably used to lower the weather deck a selected distance so thatthe weather deck is submerged and the module can be safely floated overthe weather deck for transfer to the semi-submersible heavy lift vessel.The semi-submersible heavy lift vessel then can be de-ballasted up untilthe weather deck area is above sea level. In this position, the weatherdeck supports the module so that the combination of semi-submersibleheavy lift vessel and module can travel to or from a selected naturalgas source.

[0022] In one embodiment, the method of loading the module can includesliding the module from land to the semi-submersible heavy lift vesselweather deck area.

[0023] In another embodiment, the method of loading involves liftingmultiple modules into a purpose-built, non-semi-submersible hull,utilizing a lifting device or devices that provide, e.g. external cranecapacity.

[0024] In the method of the present invention, the module may beunloaded from the semi-submersible heavy lift vessel by ballastingmethods in the water or by sliding the module onto land, in a reverseoperation from the loading steps described above. Thereafter, the modulemay be used for static storage in a permanent or semi-permanent locationon land or on the surface of the water or underwater, either suspendedbelow the surface or resting on the bottom of the waterway, lake, bay orocean.

BRIEF DESCRIPTION OF THE DRAWINGS

[0025] For a further understanding of the nature, objects, andadvantages of the present invention, reference should be had to thefollowing detailed description, read in conjunction with the followingdrawings, wherein like reference numerals denote like elements andwherein:

[0026]FIG. 1 is an elevation view of the preferred embodiment of theapparatus of the present invention;

[0027]FIG. 2 is a plan view of the preferred embodiment of the apparatusof the present invention;

[0028]FIG. 3 is a partially cut away plan view of the preferredembodiment of the apparatus of the present invention;

[0029] FIGS. 4-5 are schematic views illustrating pipe layerarrangements for use with the preferred embodiment of the apparatus ofthe present invention;

[0030]FIG. 6 is a sectional view taken along lines 6-6 of FIG. 1;

[0031]FIG. 7 is a perspective view of the preferred embodiment of theapparatus of the present invention showing transfer of the module to thesemi-submersible heavy lift vessel at a dock;

[0032]FIG. 8 is a perspective view of the preferred embodiment of theapparatus of the present invention showing transfer of the module to thesemi-submersible heavy lift vessel at a dry dock;

[0033]FIG. 9 is a perspective view of the preferred embodiment of theapparatus of the present invention showing transfer of the module from amarine transport vessel to a storage position on land;

[0034]FIG. 10 is a perspective view of the preferred embodiment of theapparatus of the present invention showing transfer of the module fromthe semi-submersible heavy lift vessel to land wherein the module islocated in a final storage position;

[0035]FIG. 11 is a perspective fragmentary view of the preferredembodiment of the apparatus of the present invention showing the pipesupport in detail;

[0036]FIG. 12 is a fragmentary view of the preferred embodiment of theapparatus of the present invention showing an alternate pipe support;

[0037]FIG. 13 is a schematic view illustrating pipe sections and fieldwelds for one of the pipe layers;

[0038]FIG. 14 is a schematic plan view illustrating field welds for oneof the layers;

[0039]FIG. 14A is a fragmentary view showing an about 180 degreeinduction bend part of the module pipeline;

[0040]FIG. 15 is a perspective fragmentary view illustrating attachmentof the semi-submersible heavy lift vessel of the present invention to aknown mooring and unloading arm;

[0041]FIG. 16 is a schematic view illustrating the top layer pipe layoutfor a barge type module;

[0042]FIG. 17 is a schematic view illustrating the second and fourthlayers of the pipe layout for a barge type module;

[0043]FIG. 18 is a schematic view illustrating the third and fifthlayers of the pipe layout for a barge type module;

[0044]FIG. 19 is a schematic view illustrating the sixth layer for apipe layout for a barge type module; and

[0045]FIG. 20 is a fragmentary, sectional view of the preferredembodiment of the apparatus of the present invention showing bargemodule and pipeline.

DETAILED DESCRIPTION OF THE INVENTION

[0046] FIGS. 1-2 and 7-8 show generally the preferred embodiment of theapparatus of the present invention designated generally by the numeral10. Compressed gas transport apparatus 10 includes a semi-submersibleheavy lift vessel 11 that has a bow 12, stern 13, port side 14,starboard side 15, upper deck 16 and lower or weather deck 17.

[0047] The semi-submersible heavy lift vessel 11 also includes a hullbottom 18, port deck wall 19 and starboard deck wall 20. A space 24 isprovided between port deck wall 19, starboard deck wall 20 and aboveweather deck 17 for carrying module 25. A module 25 can be carried bythe semi-submersible heavy lift vessel 11. Module 25 can be insertedinto or removed from space 24. Module 25 can be a floating hull such asa barge. Module 25 provides an interior 32 that carries a modulepipeline 45. The pipeline 45 includes multiple sections that are joinedtogether end to end by welds in the case of metal materials, or bypolymeric adhesives or mechanical joints in the case of composite pipematerials. Pipeline 45 includes multiple layers, such as the eight layerarrangement shown in FIGS. 3-6. Another eight layer arrangement is shownin FIGS. 16-19.

[0048] In order to load module 25 upon semi-submersible heavy liftvessel 11, two options are shown in the drawings in FIGS. 7 and 8. InFIG. 7, a load out is shown using rails, skidways or skid beams 23. Thesemi-submersible heavy lift vessel 11 is positioned next to land 21,floating in water 22 and ballasted so that the lower or weather deck 17is at about the same elevation as the elevation of land 21 upon whichmodule 25 rests. Arrow 26 in FIG. 7 illustrates the sliding movement ofmodule 25 upon beams 23 from land 21 to lower or weather deck 17 ofsemi-submersible heavy lift vessel 11.

[0049] In FIG. 8, a second method of transporting the module 25 fromland to heavy lift vessel 11 is shown. In FIG. 8, module 25 is shown ina graving dock or dry dock 70 having a gate 71 that can be closed toprevent water from entering the dry dock 70 such as during constructionof module 25. The gate 71 can be opened to flood the dry dock 70 so thatmodule 25 floats. Module 25 can then be moved in the direction of arrows28-31 from an initial position inside dry dock 70 to the adjacent bodyof water 22 and then to lower deck 17 of semi-submersible heavy liftvessel 11. During this transfer, semi-submersible heavy lift vessel 11is ballasted down a distance that submerges lower deck 17 so that themodule 25 can be floated into an area 24 that is directly above lower orweather deck 17 and in between port deck wall 19 and starboard deck wall20. The semi-submersible heavy lift vessel 11 is then de-ballasted upuntil lower deck 17 is above sea level and water surface 27. The vessel11 and its contained module 25 can travel to a selected source ofcontained compressed natural gas. The module 25 can be filled withcompressed natural gas at the selected source, and then travel to itsultimate destination for unloading.

[0050]FIGS. 9 and 10 illustrate an unloading of a module 25 from vessel20. The embodiments shown in FIGS. 9 and 10 show method steps that areutilized when the module 25 is to be unloaded from the semi-submersibleheavy lift vessel 11 by ballasting the water or by sliding as shown inFIGS. 8 and 9 in a reverse operation from the loading steps of FIG. 7.Winch 31 can pull module 25 from vessel 11 to land 21 as it slides uponrails 23. In FIG. 10, the module 25 may be used for static storage in apermanent or semi-permanent location on land 21 while on the surface ofthe water 22 or suspended below the surface of the water, or on thebottom.

[0051] Tn FIGS. 6-8, and 11-12 module 25 has a module interior 32 thatcontains pipeline 45. Module 25 can be shaped to include a bottom 34,top 33, port side 35, starboard side 36, bow 37 and stern 38. Aplurality of longitudinally extending bulkheads 39 can be provided asshown in FIG. 11. Reinforcing can be provided to module 25 under thepipeline 45 and above bottom 34, including a plurality of diagonalbraces 49 and a plurality of vertical braces 50.

[0052] The pipeline layers are supported by a plurality of pipe supports40. As shown in FIGS. 11-12, each pipe support 40 includes a web 41,upper flange 42, and lower flange 43. A curved bearing pad 44 is sizedand shaped to conform to the outer surface 46 of the pipeline 45. Asshown, the pipeline 45 is cradled with two pipe supports 40, one placedunder the pipeline 45 at a selected location and one placed above thepipeline at about the same location. The pipeline 45 has an outersurface 46, a pipeline bore 47 for holding compressed natural gas and iscomprised of a plurality of straight sections and bend sections as shownin FIGS. 3-5 and 13-20. When a plurality of the pipe supports 40 areassembled as shown, a plurality of circular openings 48 are providedthrough which a section of pipeline 45 passes.

[0053]FIG. 12 shows a non-metallic (e.g. polymeric) support 40A havingupper surface 41A with bearing pads 44A, lower surface 43A, and opposinggenerally vertical end faces 41B. Alternatively, the pipeline can besupported by a mass of encapsulating polymeric material (e.g. sprayed)that both supports and insulates the pipeline 45. Thus, the entireinterior 32 of the module 25 could be filled with an insulatingmaterial. If pipe supports 40, 40A are used (FIGS. 6, 11, 12, 20), theinterior 32 of module 25 could be filled with an inert gas. If theinterior 32 of module 25 is to be filled with inert gas, weep holes 80(see FIGS. 11 and 12) can be provided in the selected pipe support 40 or40A as shown. These weep holes 80 insure that the inert gas will flowfreely throughout the entire interior 32 of module 25.

[0054] In the embodiment shown in FIGS. 3-6, there are eight layers ofpipe sections. A plurality of the pipe layers are similarly configured.For example, in FIG. 3, the pipe layout for the first and fifth layers51 can be substantially identical. The pipe layer 52 (FIG. 4) for thesecond, fourth, sixth and eighth layers can be substantially identical.The pipe layer 53 (FIG. 5) for the third and seventh layers can beidentical. In the sectional view of FIG. 6, cross overs 54-60 are shownfor connecting a pipe layer to the pipe layer above it. Each of thelayers of pipe 51, 52, 53 includes longitudinal straight sections,transverse straight sections, and bend sections. A cross over is asection of pipe that extends from one layer to another layer that iseither above or below it.

[0055] As part of the method of the present invention, sections of pipecan be prefabricated to provide either an asymmetric bending of metalpipe or pipe that is custom built from light weight composite material,in the case of 90 degree bends; or a symmetric bend section usinginduction bending of metal pipe or pipe that is custom built from lightweight composite material, in the case of 180 degree bends. A section ofpipe that is, for example, 40 or 50 or 60 feet long is induction bent,in case of metal, or custom built with a bend (in case of compositematerial), at one end portion to provide a prefabricated bend. Theprefabricated pipe section containing a bend and one or more longstraight pieces (e.g. 68, 68A) will obviate the need for attaching anelbow fitting to any particular pipe section in the assembly of themodule in the field. Welding of metal or connecting composite pieces ofpipe is required when the asymmetric pipe sections 68 are connectedtogether or to straight pipe sections 72.

[0056] FIGS. 13-14, 14A illustrate the various asymmetric sections 68,68A of pipe having induction bends 69 before they are to be assembledtogether with straight pipe sections 72 using field welds or compositeconnections at 73. In FIGS. 13 and 1-4, pipe can be cut from anelongated string of pipe sections that are connected together. Forexample, in the case of metal, various pieces of pipe can be welded endto end to form a pipeline stalk of about 450 feet in length. In the caseof composite, pipe can be made up in desired lengths to minimize thenumber of connections. In this fashion, each of the different straightsections 72 can be cut to a preferred length before field welding ofmetal or connection of composite materials. In the case of a 180 degreesymmetric bend section 68A (FIG. 14A), the same applies.

[0057] In order to load or offload compressed natural gas, a mooring orunloading arm 66 can be provided. Such mooring/unloading arms 66 areknown in the art. They can be carried on board fixed or floatingstructures 67 including F.P.S.O.s (floating production storage andoff-loading). A fitting 65 on the vessel 11 enables a connection to bemade between pipeline 45 and mooring unloading arm 66.

[0058] A module can be placed on the FPSO for the purpose of providingstorage of compressed natural gas from oil and gas production at anoffshore location.

[0059] A module can be-placed on the surface of the water or submergedbelow the surface for the purpose of providing storage of compressednatural gas.

[0060] In FIGS. 16-20, an alternate pipe and module arrangement 74 isshown in the form of a barge module 75 utilizes a generally rectangularbarge that has exemplary dimensions of 100 feet wide and 400 feet long.In FIGS. 16-20, the pipeline 76 is of a plurality of six layers stackeddirectly one upon the other in order to minimize vertical stacking andmaximize payload. In FIG. 16, layer 76 is a first and top layer. Layer77 (FIG. 17) is the same for the second and fourth layers. Layer 78(FIG. 18) is the same configuration for the third and fifth layers.Layer 79 (FIG. 19) is the configuration for the sixth layer.

Parts List

[0061] The following is a list of suitable parts and materials for thevarious elements of the preferred embodiment of the present invention.

[0062]10 compressed natural gas transport

[0063]11 semi-submersible heavy lift vessel

[0064]12 bow

[0065]13 stern

[0066]14 port side

[0067]15 starboard side

[0068]16 upper deck

[0069]17 lower deck

[0070]18 hull bottom

[0071]19 port deck wall

[0072]20 starboard deckwall

[0073]21 land

[0074]22 water

[0075]23 skid beams

[0076]24 space

[0077]25 module

[0078]26 arrow

[0079]27 water surface

[0080]28 arrow

[0081]29 arrow

[0082]30 arrow

[0083]31 arrow

[0084]32 module interior

[0085]33 top

[0086]34 bottom

[0087]35 port side

[0088]36 starboard side

[0089]37 bow

[0090]38 stern

[0091]39 bulkhead

[0092]40 pipe support

[0093]40A support

[0094]41 web

[0095]41A upper surface

[0096]41B opposing face

[0097]42 upper flange

[0098]42A upper surface

[0099]43 lower flange

[0100]43A lower surface

[0101]44 bearing pad

[0102]44A bearing pad

[0103]45 pipeline

[0104]46 outer surface

[0105]47 pipeline bore

[0106]48 circular opening

[0107]49 diagonal brace

[0108]50 vertical brace

[0109]51 pipe layer

[0110]52 pipe layer

[0111]53 pipe layer

[0112]54 cross over

[0113]55 cross over

[0114]56 cross over

[0115]57 cross over

[0116]58 cross over

[0117]59 cross over

[0118]60 cross over

[0119]61 longitudinal straight section

[0120]62 transverse straight section

[0121]63 bend section

[0122]64 mooring arm connecting end

[0123]65 fitting

[0124]66 mooring/unloading arm

[0125]67 fender

[0126]68 asymmetric pipe section

[0127]69 induction bend

[0128]70 dry dock/graving dock

[0129]71 gate

[0130]72 straight section

[0131]73 field weld

[0132]74 pipe arrangement

[0133]75 module

[0134]76 pipeline layer

[0135]77 pipeline layer

[0136]78 pipeline layer

[0137]79 pipeline layer

[0138]80 weep hole

[0139]31 winch

[0140]82 arrow

[0141] The foregoing embodiments are presented by way of example only;the scope of the present invention is to be limited only by thefollowing claims.

1. A method of transporting natural gas in a marine environment,comprising the steps of: a) providing a heavy lift vessel that has aweather deck area; b) providing a buoyant module having an interior thatcontains a pipeline, said pipeline including multiple alternatingstraight sections and bend sections and multiple layers; and c)supporting the multiple pipeline layers at different elevations withinthe module interior; d) transferring the module to the heavy liftvessel; e) transferring natural gas from a natural gas source to themodule pipeline; f) transporting the combination of module and heavylift vessel to a selected destination while the module containingnatural gas occupies the weather deck; and g) transferring the naturalgas from the module pipeline to a selected facility.
 2. The method ofclaim 1 wherein the buoyant module has a top, bottom, and a plurality ofside walls.
 3. The method of claim 1 wherein step “d” includesballasting of the heavy lift vessel relative to the module.
 4. Themethod of claim 1 wherein the heavy lift vessel is a semi-submersibleheavy lift vessel and step “d” includes ballasting the heavy liftvessel.
 5. The method of claim 4, further comprising ballasting theheavy lift vessel down a distance that submerges the weather deck andfurther comprising the steps of floating the module to a position abovethe weather deck and ballasting the heavy lift vessel and modulerelative to one another until the weather deck supports the module abovesea level.
 6. The method of claim 5 wherein the vessel deck areasubmerges in step “d” a distance of between about 6 and 20 feet.
 7. Themethod of claim 5, further comprising de-ballasting the vessel up whilethe module is floating above the receptacle deck area.
 8. The method ofclaim 1 wherein step “d” includes sliding the module from land to thevessel weather deck area.
 9. The method of claim 1 wherein step “d”includes sliding the module from a dock to the vessel weather deck area.10. A method of transporting compressed natural gas in a marineenvironment, comprising the steps of: a) providing a heavy lift vesselthat is capable of moving under its own power in a marine environment toa location that has a compressed natural gas facility with natural gasto be transported; b) providing a module having a hollow interior and apipeline; c) filling the module pipeline with compressed natural gas; d)transporting the module with compressed natural gas inside the pipelineusing the vessel; and e) wherein ballasting and de-ballasting is used toplace the module on the vessel in steps “a”-“d”.
 11. A method of storingcompressed natural gas in a marine environment, comprising the steps of;a) moving a heavy lift vessel or a barge under its own power in a marineenvironment to a location that has a compressed natural gas facilitywith natural gas to be transported; b) providing a module having ahollow interior and a pipeline; c) filling the module pipeline withcompressed natural gas; d) storing the compressed natural gas; e)Discharging and offloading the compressed natural gas; and f) whereinballasting is used to place the module on the vessel in steps “a”-“d”.12. A method of storing compressed natural gas in a marine environment,comprising the steps of; a) moving a heavy lift vessel under its ownpower in a marine environment to a location that has a compressednatural gas facility with natural gas to be transported; b) providing amodule having a hollow interior and a pipeline; c) Ballasting the heavylift vessel and offloading the module into the water at the storagelocation; d) filling the module pipeline with compressed natural gas; e)storing the compressed natural gas until it is offloaded into acompressed natural gas carrier or a pipeline; and f) wherein ballastingis used to place the module on the vessel and off the vessel in steps“a”-“d”.
 13. A method of transporting a compressed natural gas module ina marine environment and storing compressed natural gas on land,comprising the steps of: a) moving a heavy lift vessel under its ownpower in a marine environment to a location that is to receivecompressed natural gas; b) providing a module having a hollow interiorand a pipeline; c) backing the heavy lift vessel to the dock andoffloading the module at the storage location; d) filling the modulepipeline with compressed natural gas; e) storing the compressed naturalgas until it is offloaded into a compressed natural gas carrier or apipeline; and f) wherein ballasting is used to place the module on thevessel in “a”-“f”.
 14. The method of claim 10 wherein step “b” includesprefabricating parts of the pipeline in pieces to maximize the lengthsof pieces and to minimize the number of connections in the assembly ofthe pipe module.
 15. The method of claims 10 wherein step “b” includesconnecting pieces of metal pipe by field welding end on end the sectionstogether during a fabricating of the pipeline (into sections), andplacing the pipeline inside the module.
 16. The method of claim 10wherein step “b” includes connecting pieces of composite pipe in thefield by applying adhesive binding to sleeve joints of composite pipe.17. The method of claim 10 wherein step “b” includes connecting piecesof composite pipe with rotating mechanical locking joints on each end,with the straight piece turning in one direction and locking at bothends.
 18. The method of claim 15 wherein in step “b” the pipeline isfabricated of a plurality of straight sections and a plurality of bendsections.
 19. The method of claim 15 wherein in step “b” the pipeline isfabricated of sections that have bends that are made with inductionbending.
 20. The method of claim 13 wherein at least one of the bends isan about 90 degree bend.
 21. The method of claim 20 wherein there aremultiple about 90 degree bends.
 22. The method of claim 13 wherein atleast one of the bends is an about 180 degree bend.
 23. The method ofclaim 13 wherein at least one of the bends is an about 90 degree bendand another of the bends is an about 180 degree bend.
 24. The method ofclaim 21 wherein at least one straight section of pipe has two endportions that each have a bend.
 25. The method of claim 22 wherein atleast one straight section of pipe has an end portion that has a bend ofbetween about 90-180 degrees.
 26. The method of claim 22 wherein atleast one straight section of pipe has a pair of end portions that havea bend of between about 90-180 degrees.
 27. The method of claim 15wherein the pipeline has a diameter of between about 16 and 56 inches.28. The method of claim 14 further comprising supporting the pipelinewith a plurality of racks that cradle and space apart separate sectionsof the pipeline.
 29. The method of claim 14 further comprisingconstructing the pipeline of step “b” of a plurality of generallystraight sections and a plurality of bend sections and furthercomprising the step of supporting each generally straight pipe sectionat a position spaced away from the other pipe sections.
 30. The methodof claim 14 further comprising constructing the pipeline of step “b” ofa plurality of generally straight sections and a plurality of bendsections and further comprising the step of supporting each bend pipesection at a position spaced away from the other pipe sections.
 31. Themethod of claim 18 wherein the racks include pipe support surfaces thatare shaped to continuously engage and cradle a part of the pipeline. 32.The method of claim 24 wherein the pipe support surfaces include lowfriction bearing material.
 33. The method of claim 1 wherein thepipeline has a continuous bore that is piggable.
 34. The method of claim10 wherein the pipeline has a continuous bore that is piggable.
 35. Themethod of claim 1 wherein the pipeline sections are spaced apart so thatexposed outer surfaces of the pipeline sections can be visuallyinspected.
 36. The method of claim 10 wherein the pipeline sections arespaced apart so that exposed outer surfaces of the pipeline sections canbe visually inspected.
 37. The method of claim 1 or 10 wherein themodule interior is filled with inert gas.
 38. The method of claim 37wherein the inert gas is CO₂.
 39. The method of claim 37 wherein theinert gas is nitrogen.
 40. The method of claim 37 wherein the inert gasis argon.
 41. The method of claim 37 wherein the inert gas is any fullyoxidized gas compound.
 42. The method of claim 37 wherein the gas ischilled to a temperature between about minus 30° F. and 0° F.
 43. Anatural gas pipeline module transport or storage apparatus comprising:a) a module having an interior; b) a pipeline contained within themodule interior, the pipeline having a bore; c) a marine vessel fortransporting or supporting the module; d) wherein the module rests upona deck of the vessel; and e) wherein the pipeline has multiple layers,each layer having multiple bends and multiple straight sections thatenable the pipeline to extend over substantially all of the interior.44. The transport apparatus of claim 43 wherein the vessel is either aheavy lift transport vessel or a semi-submersible transport vessel. 45.The transport or storage apparatus of claim 1 wherein the vessel iseither a new purpose build vessel or an existing vessel.
 46. Thetransport or storage apparatus of claim 46 further comprising one ormore valves for isolating portions of the pipeline.
 47. The transport orstorage apparatus of claim 33 wherein the valves have a bore that isabout the same diameter of the pipeline bore.
 48. A natural gas pipelinemodule transport or storage apparatus comprising: a) a floating modulehaving an interior; b) a pipeline contained within the module interior,the pipeline having a bore; and c) wherein the pipeline has multiplelayers, each layer having multiple bends and multiple straight sectionsthat enable the pipeline to extend over substantially all of theinterior.
 49. The transport or storage apparatus of claim 43 furthercomprising pipe supports for supporting the pipeline inside the module.50. The transport or storage apparatus of claim 49 wherein the pipesupports are metallic.
 51. The transport or storage apparatus of claim49 wherein the pipe supports are non-metallic.
 52. The transport orstorage apparatus of claim 49 wherein the pipe supports are polymeric.53. The transport or storage apparatus of claim 49 wherein the pipesupports are support members having curved support surfaces that cradlethe pipeline.
 54. The transport or storage apparatus of claim 49 whereinthe pipe supports are support members having curved support surfacesthat cradle the pipeline in positions that space sections of thepipeline apart.